Interactive virtual reality manipulation of downhole data

ABSTRACT

A method for three dimensional visualization and manipulation of downhole data. A measured signal is received a downhole environment and a three dimensional virtualization of the measured signal is generated. A stereographic viewer displays the three dimensional virtualization of the measured signal. The three dimensional virtualization can be manipulated in response to an input from a user, thereby creating a manipulated three dimensional virtualization. The stereographic viewer can display the manipulated three dimensional virtualization.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application is a continuation of U.S. application Ser. No.16/609,267 filed Oct. 29, 2019, which claims benefit to national stageentry of PCT/US2017/039779 filed Jun. 28, 2017, said application isexpressly incorporated herein in its entirety.

FIELD

The subject matter herein generally relates to a system and method formanipulating data using an interactive virtual reality device, and inparticular, visualizing and manipulating data obtained in a downholeenvironment.

BACKGROUND

Visualization of downhole data has been limited to representation on atwo dimensional display, or a three dimensional display lackinginteractivity. Two dimensional display prevents a user from activelyvisualizing the downhole data as it exists within a formation orwellbore. A three dimensional display provides visualization, butprevents manipulation of the downhole data and/or adjustment of wellboreoperations in response to the three dimensional display.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1A is a diagrammatic of an embodiment of a wellbore drillingoperation from which downhole data can be obtained for use with aninteractive virtual reality system and method, according to an exemplaryembodiment;

FIG. 1B is a diagrammatic of an embodiment of a wellbore operatingenvironment from which downhole data can be obtained for use with aninteractive virtual reality system and method, according to an exemplaryembodiment;

FIG. 2 is diagrammatic view of an interactive three dimensional virtualreality system for downhole data manipulation;

FIG. 3A is an isometric view of a stereographic display device of aninteractive three dimensional virtual reality system according to anexemplary embodiment;

FIG. 3B is diagrammatic view of a stereographic display arrangement;

FIG. 4A is an isometric view of a gesture control device of aninteractive three dimensional virtual reality system according to anexemplary embodiment;

FIG. 4B is an isometric view of a second gesture control device of aninteractive three dimensional virtual reality system according to anexemplary embodiment;

FIG. 4C is an isometric view of a third gesture control device of aninteractive three dimensional virtual reality system according to anexemplary embodiment;

FIG. 5 is a diagrammatic view of an interactive three dimensionalvirtual reality system;

FIG. 6 is a diagrammatic view of a conventional system bus computingsystem architecture, according to an exemplary embodiment;

FIG. 7 is a diagrammatic view of a computer system having a chipsetarchitecture, according to an exemplary embodiment;

FIG. 8 is a flow chart of an interactive three dimensional virtualreality system according to an exemplary embodiment;

FIG. 9 is a flow chart of an interactive three dimensional virtualreality system for a well logging operation;

FIG. 10 is a flow chart of an interactive three dimensional virtualreality system for a cased-hole pipe service operation;

FIG. 11 is a flow chart of an interactive three dimensional virtualreality system for a well monitoring operation;

FIG. 12 is a flow chart of an interactive three dimensional virtualreality system for a permanent reservoir monitoring operation;

FIG. 13 is a flow chart of an interactive three dimensional virtualreality system for a drilling operation;

FIG. 14 is a flow chart of an interactive three dimensional virtualreality system having an augmented reality for a drilling operation;

FIG. 15A is a flow chart of an interactive three dimensional virtualreality system for adjusting mud type;

FIG. 15B is a flow chart of a second an interactive three dimensionalvirtual reality system for adjusting mud type;

FIG. 16 is a flow chart of an interactive three dimensional virtualreality system for a downhole measurement operation;

FIG. 17A is a flow chart of an interactive three dimensional virtualreality system for comparing downhole measurements;

FIG. 17B is a diagrammatic view of comparing downhole measurements;

FIG. 18A is a flow chart of an interactive three dimensional virtualreality system for comparing downhole measurements from different tools;and

FIG. 18B is a diagrammatic view of comparing downhole measurements fromdifferent tools;

DETAILED DESCRIPTION

It will be appreciated that for simplicity and clarity of illustration,where appropriate, reference numerals have been repeated among thedifferent figures to indicate corresponding or analogous elements. Inaddition, numerous specific details are set forth in order to provide athorough understanding of the embodiments described herein. However, itwill be understood by those of ordinary skill in the art that theembodiments described herein can be practiced without these specificdetails. In other instances, methods, procedures and components have notbeen described in detail so as not to obscure the related relevantfeature being described. Also, the description is not to be consideredas limiting the scope of the embodiments described herein. The drawingsare not necessarily to scale and the proportions of certain parts havebeen exaggerated to better illustrate details and features of thepresent disclosure.

In the following description, terms such as “upper,” “upward,” “lower,”“downward,” “above,” “below,” “downhole,” “uphole,” “longitudinal,”“lateral,” and the like, as used herein, shall mean in relation to thebottom or furthest extent of the surrounding wellbore even though thewellbore or portions of it may be deviated or horizontal.Correspondingly, the transverse, axial, lateral, longitudinal, radial,etc., orientations shall mean orientations relative to the orientationof the wellbore or tool. Unless otherwise specified, any use of any formof the term “couple,” or any other term describing an interactionbetween elements is not meant to limit the interaction to directinteraction between the elements and also may include indirectinteraction between the elements described.

The term “inside” indicate that at least a portion of a region ispartially contained within a boundary formed by the object. The term“substantially” is defined to be essentially conforming to theparticular dimension, shape or other word that substantially modifies,such that the component need not be exact. For example, substantiallycylindrical means that the object resembles a cylinder, but can have oneor more deviations from a true cylinder.

The term “parallax” as described herein means a displacement ordifference in the apparent position of an object viewed along two linesof sign, and is measured by the angle or semi-angle of inclinationbetween two lines.

The present disclosure is drawn to an interactive virtual reality systemand related method for controlling and manipulating downhole data andoperations using the interactive virtual reality system. The interactivevirtual reality system for visualization and manipulation of downholedata can include an interactive virtual reality apparatus having astereographic display device and a gesture control device, and anelectronic device communicatively coupled with the interactive virtualreality apparatus. The electronic device can have a processor and/ormemory, and the memory can store instructions, which when executed cancause the processor to receive a measured signal of a downholeenvironment, generate a three dimensional virtualization of the measuredsignal, communicate the three dimensional virtualization to theinteractive virtual reality apparatus, manipulate the three dimensionalvirtualization in response to an input from the interactive virtualreality apparatus, thereby creating a manipulated three dimensionalvirtualization, and communicate the manipulated three dimensionalvirtualization to the interactive virtual reality apparatus. Themeasured signal can be one of a voltage, a current, an impedance, aformation property, a casing property, a casing defect, a temperature, apressure, a chemical composition, a distance to water, a distance tocarbon dioxide, a distance to a bed boundary (DTBB), a calipermeasurement, and/or a resistivity function of space, time, or space andtime.

FIG. 1A illustrates a wellbore operating environment having a welllogging apparatus 150. The well logging apparatus 150 can conduct welllogging during drilling operations in a subterranean well environment. Awellbore 48 is shown that has been drilled into the earth 54 from theground's surface 127 using a drill bit 22. The drill bit 22 is locatedat the bottom, distal end of the drill string 32 and the bit 22 anddrill string 32 are being advanced into the earth 54 by the drilling rig29. The drilling rig 29 can be supported directly on land as shown or onan intermediate platform if at sea. For illustrative purposes, the topportion of the wellbore includes casing 34 that is typically at leastpartially made up of cement and which defines and stabilizes thewellbore after being drilled. The drill bit 22 can be rotated viarotating the drill string, and/or a downhole motor near the drill bit22.

As shown in FIG. 1A, the drill string 32 supports several componentsalong its length, including a well logging apparatus 150. A sensorsub-unit 52 is shown for detecting conditions near the drill bit 22,conditions which can include such properties as formation fluid density,temperature and pressure, and azimuthal orientation of the drill bit 22or string 32. Measurement while drilling (MWD)/logging while drilling(LWD) procedures are supported both structurally and communicatively.The instance of directional drilling is illustrated in FIG. 1A. Thelower end portion of the drill string 32 can include a drill collarproximate to the drilling bit 22 and a drilling device such as a rotarysteerable drilling device 20, or other drilling devices disclosedherein. The drill bit 22 may take the form of a roller cone bit or fixedcutter bit or any other type of bit known in the art. The sensorsub-unit 52 is located in or proximate to the rotary steerable drillingdevice 20 and advantageously detects the azimuthal orientation of therotary steerable drilling device 20. Other sensor sub-units 35, 36 areshown within the cased portion of the well which can be enabled to sensenearby characteristics and conditions of the drill string, formationfluid, casing and surrounding formation. Regardless of which conditionsor characteristics are sensed, data indicative of those conditions andcharacteristics is either recorded downhole, for instance at theprocessor 44 for later download, or communicated to the surface eitherby wire using repeaters 37, 39 up to surface wire 72, or wirelessly orotherwise. If wirelessly, the downhole transceiver (antenna) 38 can beutilized to send data to a local processor 18, via topside transceiver(antenna) 14. There the data may be either processed or furthertransmitted along to a remote processor 12 via wire 16 or wirelessly viaantennae 14 and 10.

Coiled tubing 178 and/or wireline 30 can be deployed as an independentservice upon removal of the drill string 32 (shown for example in FIG.1B). The possibility of an additional mode of communication iscontemplated using drilling mud 40 that is pumped via conduit 42 to adownhole mud motor 76. The drilling mud is circulated down through thedrill string 32 and up the annulus 33 around the drill string 32 to coolthe drill bit 22 and remove cuttings from the wellbore 48. For purposesof communication, resistance to the incoming flow of mud can bemodulated downhole to send backpressure pulses up to the surface fordetection at sensor 74, and from which representative data is sent alongcommunication channel 121 (wired or wirelessly) to one or moreprocessors 18, 12 for recordation and/or processing.

The sensor sub-unit 52 is located along the drill string 32 above thedrill bit 22. The sensor sub-unit 36 is shown in FIG. 1A positionedabove the mud motor 76 that rotates the drill bit 22. Additional sensorsub-units 35, 36 can be included as desired in the drill string 32. Thesub-unit 52 positioned below the motor 76 communicates with the sub-unit36 in order to relay information to the surface 127.

A surface installation 19 is shown that sends and receives data to andfrom the well. The surface installation 19 can exemplarily include alocal processor 18 that can optionally communicate with one or moreremote processors 12, 17 by wire 16 or wirelessly using transceivers 10,14.

The exemplary rotary steerable drilling device 20 schematically shown inFIG. 1A can also be referred to as a drilling direction control deviceor system. As shown, the rotary drilling device 20 is positioned on thedrill string 32 with drill bit 22. However, one of skill in the art willrecognize that the positioning of the rotary steerable drilling device20 on the drill string 22 and relative to other components on the drillstring 22 may be modified while remaining within the scope of thepresent disclosure.

FIG. 1B illustrates a wellbore operating environment in which the welllogging apparatus, method, and system can be deployed, according to anexemplary embodiment of the present disclosure. As depicted, theoperating environment 100 includes a drilling platform 120 equipped witha derrick 125 that supports a hoist 115. Drilling oil and gas wells iscommonly carried out using a string of drill pipes connected together soas to form a drilling string that is lowered through a rotary table 110into a wellbore or borehole 140.

Here it is assumed that the drill string has been temporarily removedfrom the wellbore 140 to allow the well logging apparatus 150 to belowered into the wellbore 140. The well logging apparatus 150 mayinclude one or more sensors, receivers and/or transmitters forconducting logging and measuring operations as disclosed herein. Thewell logging apparatus 150 can be conveyed in the wellbore 140 by anyconveyance 130 including, but not limited to, wireline, logging cable,slickline, tubing, coiled tubing, pipe, metallic wire, non-metallicwire, composite wire, or downhole tractor. The well logging apparatus150 may have a local power supply, such as batteries, downhole generatorand the like. When employing non-conductive cable, coiled tubing, pipestring, or downhole tractor, communication may be supported using, forexample, wireless protocols (e.g. EM, acoustic, etc.), and/ormeasurements and logging data may be stored in local memory forsubsequent retrieval. Typically, the well logging apparatus 150 islowered to the bottom of the region of interest and subsequently pulledupward at a substantially constant speed. During the upward trip, one ormore sensors in the well logging apparatus 150 may be used to performmeasurements on the subsurface formations 180 adjacent to the wellbore140 as they pass by. However, measurements can be performed on bothdownward and upward movements of the well logging apparatus 150.

The measurement data can be communicated to a logging facility 170 forstorage, processing, and analysis. The logging facility 170 may beprovided with electronic equipment for various types of signalprocessing. For example, the logging facility 170 may include one ormore well logging data processing units 174 for the processing of welllogging data. In some cases, the well logging data processing unit 174can be communicatively coupled to one or more displays 172, including aninteractive virtual reality apparatus as described below with respect toFIG. 2 .

In some cases, the well logging data apparatus 150 can be housed in adownhole tool body comprising additional downhole logging tools. In somecases, the logging facility 170 may store, process, and/or analyzelogging data from more than one downhole logging tools.

Although FIGS. 1A and 1B depict a vertical wellbore 136, the presentdisclosure is equally well-suited for use in wellbores having otherorientations including horizontal wellbores, slanted wellbores,multilateral wellbores or the like. Also, even though FIGS. 1A and 1Bdepict an onshore operation, the present disclosure is equallywell-suited for use in offshore operations.

Although FIG. 1B shows an exemplary environment relating to well loggingin the absence or temporary cessation of drilling operations, thepresent disclosure is equally well-suited for use in “logging whiledrilling” (LWD) operations, for example, as shown in FIG. 1A. As such,the present disclosure is equally well-suited for use in operationswhere the drilling assembly includes the well logging apparatus therebyproviding for well data acquisition during drilling operations, whenmeasurements may be less affected by fluid invasion.

While FIGS. 1A and 1B depict an onshore drilling rig, the presentdisclosure is equally well-suited to use in offshore drillingoperations. Offshore oil rigs that can be used in accordance with thepresent disclosure include, for example, floaters, fixed platforms,gravity-based structures, drillships, semi-submersible platform, jack-updrilling rigs, tension-leg platforms, and the like. The presentdisclosure is suited for use in rigs ranging anywhere from small in sizeand portable, to bulky and permanent.

FIG. 2 illustrates an interactive virtual reality apparatus 200according the present disclosure. The interactive virtual realityapparatus 200 can be implemented during a MWD/LWD or other loggingoperation as described above with respect to FIGS. 1A and 1B or can beimplemented with data obtained from operations described above withrespect to FIGS. 1A and 1B. The interactive virtual reality apparatus200 can include a stereographic display device 202 and a gesture controldevice 204. The stereographic display device 202 can be worn by a userto visualize a three dimensional visualization 206 of downhole data onad display 210 (shown in FIG. 3B). The stereographic display device 202can have one or more sensors to measure a user's gaze and the locationand orientation of a user's head.

The stereographic display device 202 can present virtual user controls208 on the display 210 to allow a user to interact with the threedimensional visualization 206. The user controls 208 can be overlaid onthe three dimensional visualization 206 or displayed separately in anunused portion of the display 210. In some instances, the user controls208 are direction controls to adjust the three dimensional visualization206 on the display 210. In other instances, the user controls 208 arenotations, filters, comment boxes, or other designators to manipulatethe three dimensional visualization 206.

The gesture control device 204 can allow the user to interact with thethree dimensional visualization 206 and the user controls 208. Thegesture control device 204 can receive an input from a user andmanipulate the three dimensional visualization 206 in response to theinput. The input can adjust the view of the three dimensionalvisualization 206, apply a filter to the three dimensional visualization206, or open a comment box to provide notation within the threedimensional visualization 206.

The input received from the gesture control device 204 can be a usermovement, including but not limited to, rotation, lateral/vertical orany movement therebetween, or command provided by a user's hand. Asdepicted in FIG. 2 , the gesture control device 204 can be one or moregloves disposed around a user's hand(s) and configured to track spatialmovement of the hand relative to the three dimensional visualization206. Additional embodiments of a gesture control device are describedwith respect to FIGS. 4A-4C.

FIG. 3A illustrates an example embodiment of a stereographic displaydevice 202. The stereographic display device 202 can have one or morestraps 212 to secure the stereographic display device 202 to a user'shead. The one or more straps 212 can include an adjustable lateral strap214 coupled with opposing sides of the stereographic display device 202and an adjustable support strap coupled with the upper surface of thestereographic display device 202 and the lateral strap 214. The one ormore straps 212 can be adjustable to various the lengths and accommodatea variety of users and can be formed from an elastic material providinga compressive yet comfortable fit. In some instances, the stereographicdisplay device 202 is a housing configured to receive an electronicdevice having a display. In other instances, the stereographic displaydevice 202 has a display disposed therein.

FIG. 3B illustrates a stereographic display. The stereographic displaydevice 202 can project two distinct images associated with a user's leftand right eye, respectively, as would be experienced if viewed by theuser's naked eye and the brain interprets the combined image as havingthe correct depth, thereby generating a three dimensional virtualization206 (shown in FIG. 2 ).

The display 210 can be formed by the two independent displays or onedisplay with the two distinct images 216, 218 displayed on verticallyadjacent halves so as to be viewed by individual eyes. As depicted inFIG. 3B, the stereographic display 210 has a left screen 216 and a rightscreen 218. These images are viewed as partially overlapping, asdepicted by virtual screens 220, 222, by the user's brain to perceivedepth and produce a three dimensional virtualization 206.

FIGS. 4A, 4B, and 4C illustrate example embodiments of a gesture controldevice 204. As depicted in FIG. 4A, the gesture control device 204 canbe a glove 224 worn by a user. The glove 224 can have one or moresensors 226 to detect motion or movement of a user's hand within theglove 224. The one or more sensors 226 can be strain/stress sensors todetect movement of a hand and/or fingers, or can be anaccelerometer/gyroscopic sensors to detect motion of a hand and/orfingers. In other instances, the glove 224 can include pressure/contactsensors to detect the glove's 224 interaction with an environment orother pressure sensors (for example, two fingers pinching each other).

As depicted in FIG. 4B, the gesture control device 204 can be acontroller 228 held by a user in one hand or both hands. The controller228 can include one or more buttons and/or joysticks to receive inputfrom a user. The controller 228 can additionally include one or moresensors as described above, such accelerometer/gyroscopic sensors todetect movement of the controller. The controller 228 can wirelesslycouple with a base station 229 coupled with the system 200.

As depicted in FIG. 4C, the gesture control device 204 can be a motioncontroller 230 configured to wireless detect the movement or motion of auser's. The motion controller 230 can be a camera configured to track auser's hands movements using advanced image processing. The motioncontroller 230 may obviate any handheld device such as a glove 224 orhandheld controller 228, but requires line of sight between the usershands and the camera at all times. The motion controller 230 is notlimited to hand movement or gestures and can be configured to track auser's head, other appendages (for example, legs) or any other object(for example, pencil).

While example embodiments of gesture control devices are describedabove, other gesture control devices can be implemented within thepresent disclosure. The stereographic display device 202 can beimplemented with a gesture control device 204 disposed therein fortracking the movement and motion of a user's head. The head trackingdevice can be a motion controller 230 and/or one or more sensors such asaccelerometer/gyroscopic sensors.

FIG. 5 illustrates an interactive virtual reality apparatus 200. Theinteractive virtual reality apparatus 200 can include the stereographicdisplay device 202 (also referred to as a headset), a gesture controldevice 204 (also referred to as an input device), a processor 232, adownhole measurement device 234, and downhole operation controls 236.

The stereographic display device 202 and gesture control apparatus 204can be coupled with the processor 232. The processor can include acentral processing unit (CPU) and/or a graphical processing unit (GPU),as well an operating system. In some instances, the processor 232 andthe gesture control device 204 are disposed within the stereographicdisplay device 202.

The processor 232 sends and receives signals from the stereographicdisplay device 202 and receives input from the gesture control device204. The processor 232 can also be coupled with a downhole measurementdevice 234. The downhole measurement device 234 provides a measuredsignal with information relating to a downhole environment. The downholemeasurement device 234 can be a open-hole or cased-hole logging tool,MWD/LWD tool, or a permanent monitoring system. The processor 232 cansend and receive signals from the downhole measurement device 234 inreal time during operations, or can receive a previously measured signalfrom the downhole measurement device 234. The processor 232 can form athree dimensional visualization of the downhole environment from thesignals received from the downhole measurement device 234 and displaythe visualization on the stereographic display device 202.

The processor 232 can also be communicatively coupled with a downholeoperation controls 236 and allow the interactive virtual realityapparatus to send signals from the gesture control apparatus 204 to thedownhole operations control 236. In a MWD or LWD scenario, the processor232 can receive an input from the gesture control device 204 in responseto a visualization on the stereographic display device 202 and theprocessor 232 can send command to the downhole operations control 236control the downhole operation, such as logging, monitoring, ordrilling, and/or to perform corrective action.

In some instances, the processor 232 can receive an input signal fromthe gesture control device 204 and send a command to the downholemeasurement device 234 and downhole operations control 236 to alter thedrilling operation direction.

FIG. 6 illustrates a conventional system bus computing systemarchitecture 600 wherein the components of the system are in electricalcommunication with each other using a bus 605. System 600 can include aprocessing unit (CPU or processor) 610 (which may be the same asprocessor 232 as described in FIG. 5 for implementing the interactivevirtual reality system disclosed herein) and a system bus 605 thatcouples various system components including the system memory 615, suchas read only memory (ROM) 620 and random access memory (RAM) 635, to theprocessor 610. The system 600 can include a cache of high-speed memoryconnected directly with, in close proximity to, or integrated as part ofthe processor 610. The system 600 can copy data from the memory 615and/or the storage device 630 to the cache 612 for quick access by theprocessor 610. In this way, the cache 612 can provide a performanceboost that avoids processor 610 delays while waiting for data. These andother modules can control or be configured to control the processor 610to perform various actions. Other system memory 615 may be available foruse as well. The memory 615 can include multiple different types ofmemory with different performance characteristics. It can be appreciatedthat the disclosure may operate on a computing device 600 with more thanone processor 610 or on a group or cluster of computing devicesnetworked together to provide greater processing capability. Theprocessor 610 can include any general purpose processor and a hardwaremodule or software module, such as first module 632, second module 634,and third module 636 stored in storage device 630, configured to controlthe processor 610 as well as a special-purpose processor where softwareinstructions are incorporated into the actual processor design. Theprocessor 610 may essentially be a completely self-contained computingsystem, containing multiple cores or processors, a bus, memorycontroller, cache, etc. A multi-core processor may be symmetric orasymmetric.

The system bus 605 may be any of several types of bus structuresincluding a memory bus or a memory controller, a peripheral bus, and alocal bus using any of a variety of bus architectures. A basicinput/output (BIOS) stored in ROM 620 or the like, may provide the basicroutine that helps to transfer information between elements within thecomputing device 600, such as during start-up. The computing device 600further includes storage devices 630 or computer-readable storage mediasuch as a hard disk drive, a magnetic disk drive, an optical disk drive,tape drive, solid-state drive, RAM drive, removable storage devices, aredundant array of inexpensive disks (RAID), hybrid storage device, orthe like. The storage device 630 can include software modules 632, 634,636 for controlling the processor 610. The system 600 can include otherhardware or software modules. The storage device 630 is connected to thesystem bus 605 by a drive interface. The drives and the associatedcomputer-readable storage devices provide non-volatile storage ofcomputer-readable instructions, data structures, program modules andother data for the computing device 600. In one aspect, a hardwaremodule that performs a particular function includes the softwarecomponents shorted in a tangible computer-readable storage device inconnection with the necessary hardware components, such as the processor610, bus 605, and so forth, to carry out a particular function. In thealternative, the system can use a processor and computer-readablestorage device to store instructions which, when executed by theprocessor, cause the processor to perform operations, a method or otherspecific actions. The basic components and appropriate variations can bemodified depending on the type of device, such as whether the device 600is a small, handheld computing device, a desktop computer, or a computerserver. When the processor 610 executes instructions to perform“operations”, the processor 610 can perform the operations directlyand/or facilitate, direct, or cooperate with another device or componentto perform the operations.

To enable user interaction with the computing device 600, an inputdevice 645 can represent any number of input mechanisms, such as agesture control device disclosed herein, as well as other inputs such asa microphone for speech, a touch-sensitive screen for gesture orgraphical input, keyboard, mouse, motion input, speech and so forth. Anoutput device 642 can include the stereographic display device displayherein, or display screen or other graphical user interface, and mayalso be one or more of a number of output mechanisms known to those ofskill in the art. In some instances, multimodal systems can enable auser to provide multiple types of input to communicate with thecomputing device 600. The communications interface 640 can generallygovern and manage the user input and system output. There is norestriction on operating on any particular hardware arrangement andtherefore the basic features here may easily be substituted for improvedhardware or firmware arrangements as they are developed.

Storage device 630 is a non-volatile memory and can be a hard disk orother types of computer readable media which can store data that areaccessible by a computer, such as magnetic cassettes, flash memorycards, solid state memory devices, digital versatile disks (DVDs),cartridges, RAMs 625, ROM 620, a cable containing a bit stream, andhybrids thereof.

The logical operations for carrying out the disclosure herein mayinclude: (1) a sequence of computer implemented steps, operations, orprocedures running on a programmable circuit with a general usecomputer, (2) a sequence of computer implemented steps, operations, orprocedures running on a specific-use programmable circuit; and/or (3)interconnected machine modules or program engines within theprogrammable circuits. The system 600 shown in FIG. 6A can practice allor part of the recited methods, can be a part of the recited systems,and/or can operate according to instructions in the recited tangiblecomputer-readable storage devices.

One or more parts of the example computing device 600, up to andincluding the entire computing device 600, can be virtualized. Forexample, a virtual processor can be a software object that executesaccording to a particular instruction set, even when a physicalprocessor of the same type as the virtual processor is unavailable. Avirtualization layer or a virtual “host” can enable virtualizedcomponents of one or more different computing devices or device types bytranslating virtualized operations to actual operations. Ultimatelyhowever, virtualized hardware of every type is implemented or executedby some underlying physical hardware. Thus, a virtualization computelayer can operate on top of a physical compute layer. The virtualizationcompute layer can include one or more of a virtual machine, an overlaynetwork, a hypervisor, virtual switching, and any other virtualizationapplication.

The processor 610 can include all types of processors disclosed herein,including a virtual processor. However, when referring to a virtualprocessor, the processor 610 includes the software components associatedwith executing the virtual processor in a virtualization layer andunderlying hardware necessary to execute the virtualization layer. Thesystem 600 can include a physical or virtual processor 610 that receivesinstructions stored in a computer-readable storage device, which causesthe processor 610 to perform certain operations. When referring to avirtual processor 610, the system also includes the underlying physicalhardware executing the virtual processor 610.

FIG. 7 illustrates an example computer system 750 having a chipsetarchitecture that can be used in executing the described method andgenerating and displaying a graphical user interface (GUI). Computersystem 750 can be computer hardware, software, and firmware that can beused to implement the disclosed technology. System 750 can include aprocessor 755 (which may be the same as processor 232 as described inFIG. 5 for implementing the interactive virtual reality system disclosedherein), representative of any number of physically and/or logicallydistinct resources capable of executing software, firmware, and hardwareconfigured to perform identified computations. Processor 755 cancommunicate with a chipset 760 that can control input to and output fromprocessor 755. Chipset 760 can output information to output device 765,such as a display, and can read and write information to storage device770, which can include magnetic media, and solid state media. Chipset760 can also read data from and write data to RAM 775. A bridge 780 forinterfacing with a variety of user interface components 785 can includea keyboard, a microphone, touch detection and processing circuitry, apointing device, such as a mouse, and so on. In general, inputs tosystem 750 can come from any of a variety of sources, machine generatedand/or human generated.

Chipset 760 can also interface with one or more communication interfaces790 that can have different physical interfaces. Such communicationinterfaces can include interfaces for wired and wireless local areanetworks, for broadband wireless networks, as well as personal areanetworks. Some applications of the methods for generating, displaying,and using the GUI disclosed herein can include receiving ordereddatasets over the physical interface or be generated by the machineitself by processor 755 analyzing data stored in storage 770 or RAM 775.Further, the machine can receive inputs from a user via user interfacecomponents 785 and execute appropriate functions, such as browsingfunctions by interpreting these inputs using processor 755.

It can be appreciated that systems 700 and 750 can have more than oneprocessor 610, 755 or be part of a group or cluster of computing devicesnetworked together to provide processing capability. For example, theprocessor 610, 755 can include multiple processors, such as a systemhaving multiple, physically separate processors in different sockets, ora system having multiple processor cores on a single physical chip.Similarly, the processor 610 can include multiple distributed processorslocated in multiple separate computing devices, but working togethersuch as via a communications network. Multiple processors or processorcores can share resources such as memory 715 or the cache 612, or canoperate using independent resources. The processor 610 can include oneor more of a state machine, an application specific integrated circuit(ASIC), or a programmable gate array (PGA) including a field PGA.

Methods according to the aforementioned description can be implementedusing computer-executable instructions that are stored or otherwiseavailable from computer readable media. Such instructions can compriseinstructions and data which cause or otherwise configured a generalpurpose computer, special purpose computer, or special purposeprocessing device to perform a certain function or group of functions.portions of computer resources used can be accessible over a network.The computer executable instructions may be binaries, intermediateformat instructions such as assembly language, firmware, or source code.Computer-readable media that may be used to store instructions,information used, and/or information created during methods according tothe aforementioned description include magnetic or optical disks, flashmemory, USB devices provided with non-volatile memory, networked storagedevices, and so on.

For clarity of explanation, in some instances the present technology maybe presented as including individual functional blocks includingfunctional blocks comprising devices, device components, steps orroutines in a method embodied in software, or combinations of hardwareand software. The functions these blocks represent may be providedthrough the use of either shared or dedicated hardware, including, butnot limited to, hardware capable of executing software and hardware,such as a processor 610, that is purpose-built to operate as anequivalent to software executing on a general purpose processor. Forexample, the functions of one or more processors represented in FIG. 6may be provided by a single shared processor or multiple processors (useof the term “processor” should not be construed to refer exclusively tohardware capable of executing software.) Illustrative embodiments mayinclude microprocessor and/or digital signal processor (DSP) hardware,ROM 620 for storing software performing the operations described below,and RAM 635 for storing results. Very large scale integration (VLSI)hardware embodiments, as well as custom VLSI circuitry in combinationwith a general purpose DSP circuit, may also be provided.

The computer-readable storage devices, mediums, and memories can includea cable or wireless signal containing a bit stream and the like.However, when mentioned, non-transitory computer-readable storage mediaexpressly exclude media such as energy, carrier signals, electromagneticwaves, and signals per se.

Devices implementing methods according to these disclosures can comprisehardware, firmware and/or software, and can take any of a variety ofform factors. Such form factors can include laptops, smart phones, smallform factor personal computers, personal digital assistants, rackmountdevices, standalone devices, and so on. Functionality described hereinalso can be embodied in peripherals or add-in cards. Such functionalitycan also be implemented on a circuit board among different chips ordifferent processes executing in a single device.

The instructions, media for conveying such instructions, computingresources for executing them, and other structures for supporting suchcomputing resources are means for providing the functions described inthese disclosures.

FIG. 8 illustrates an example method for using an interactive virtualreality apparatus 100. Referring to FIG. 8 , a flowchart is presented inaccordance with an example embodiment. The example method 800 isprovided by way of example, as there are a variety of ways to carry outthe method 800. The method 800 described below can be carried out usingthe configurations illustrated in FIGS. 1-7 , for example, and variouselements of these figures are referenced in explaining example method800. Each block shown in FIG. 8 represents one or more processes,methods or subroutines, carried out in the example method 800.Furthermore, the illustrated order of blocks is illustrative only andthe order of the blocks can change according to the present disclosure.Additional blocks may be added or fewer blocks may be utilized, withoutdeparting from this disclosure. The example method 800 can begin atblock 802.

At block 802, the method 800 can have a casing, borehole, or formationproperty. The casing, borehole, or formation property can be configuredto receive one or more downhole measurement devices, such as a drillstring with MWD sensors, a well logging apparatus or a permanent wellmonitoring tool.

At block 804, the downhole measurement device can be inserted into thecasing, wellbore, or formation. The downhole measurement device can bereceived during drilling operations (shown in FIG. 1A) or during a pausein drilling operations (shown in FIG. 1B). The downhole measurementdevice can include, but is not limited to, a resistivity logging tool,corrosion inspection tool, and a permanently installed reservoirmonitoring tool.

At block 806, the downhole measurement device generates a measuredsignal. The measured signal can be a data set acquired by the downholemeasurement device relative to the downhole environment.

At block 808, the measured signal is interpreted. Interpretation of themeasured signal allows the data set acquired by the downhole measurementdevice to form a graphic representation of the downhole environment.

At block 810, the interpreted measured signal generates a threedimensional virtualization. The three dimensional virtualization can bea two dimensional representation of the measured signal, but havingthree dimensional properties for display by the stereographic displaydevice.

At block 812, the three dimensional virtualization can form a threedimensional model of the casing, borehole, or formation property. Insome instances, the three dimensional virtualization and threedimensional model can be the same and/or the method 800 can implementthe three dimensional virtualization and three dimensional modelsimultaneously.

At block 814, the three dimensional model is presented to astereographic display device. The stereographic display device isconfigured to be worn by a user to present the three dimensional model.

At block 816, the stereographic display device presents the user withtwo distinct images. A left image is displayed for viewing by the user'sleft eye and a right image is displayed for viewing by the user's righteye.

At block 818, the left image and right image form a stereo projection asshown in FIG. 3B. The stereo image involves the left image and the rightimage being viewed by the corresponding user eye. The left and rightimage have a parallax between them.

At block 820, a visualization can be generated by the user induced bythe user viewing the left image and the right image. The user's braininterprets the parallax between the two images as depth, thereby causingthe user to see a three dimensional visualization of the measuredsignal.

At block 822, the method 800 can receive a user input from a gesturecontrol device in response to the visualization. The user input from thegesture control device can be finger/hand manipulation, head movement,speech, gaze, or another gesture received by the stereographic displaydevice or gesture control device. In some instances, the user input canbe null.

At block 824, the user input can manipulate the visualization andcontents of the three dimensional view. The user can pan, zoom in/out,and rotate the view of the visualization displayed by the stereographicdisplay device. Scroll bars, dropdown menus, check boxes, radio buttons,and similar graphical user interface (GUI) features can be presentedwithin the within the visualization for input from the gesture controldevice.

At block 826, a process control can manipulate the downhole measurementdevice in response to the input received from the gesture controldevice. The input from the gesture control device can manipulate theview, the data, or the entire measurement and/or drilling process. Insome instances, the process control can manipulate the measured signalor the three dimensional virtualization depending on the input receivedfrom the gesture control device and/or the process being implemented.For example, a gesture to zoom in/out can manipulate the threedimensional virtualization or a gesture for a comment box can manipulatethe measured signal.

FIG. 9 illustrates an example method 900 for using an interactivevirtual reality apparatus 100 within an open-hole or cased holeenvironment. The method 900 can be a specific iteration of method 800described above with respect to FIG. 8 . Referring to FIG. 9 , aflowchart is presented in accordance with an example embodiment. Theexample method 900 is provided by way of example, as there are a varietyof ways to carry out the method 900. The method 900 described below canbe carried out using the configurations illustrated in FIGS. 1-8 , forexample, and various elements of these figures are referenced inexplaining example method 900. Each block shown in FIG. 9 represents oneor more processes, methods or subroutines, carried out in the examplemethod 900. Furthermore, the illustrated order of blocks is illustrativeonly and the order of the blocks can change according to the presentdisclosure. Additional blocks may be added or fewer blocks may beutilized, without departing from this disclosure. The example method 900can begin at block 902.

At block 902, a well-logging measurement of an open-hole or cased-holeis made. The downhole measurement can be an open-hole or cased-holewell-logging operation.

At block 904, the formation signal is measured to generate a measuredsignal. The formation signal can measure resistivity, slowness,porosity, etc.

At block 906, the formation property(s) are interpreted.

At block 908, colored equal surfaces, or colored volumetric fog isconstructed. The interpreted formation property(s) can be visuallyrepresented in three dimensions by a colored iso-parameter surface orcolored volumetric fog. Each formation property can be visuallyrepresented by a different iso-parameter surface or colored volumetricfog. In some instances, multiple formation properties can be overlaidand viewed collectively or individually.

At block 910, a visualization of the outside and/or inside of theborehole is created. The visualization can be presented to the user by astereographic display device. The visualization can be a threedimensional view of the colored iso-parameter surface or coloredvolumetric fog.

At block 912, the visualization of the borehole (outside and/or inside)is manipulated by the gesture control device. The gesture control devicecan manipulate the view of the visualization, manipulate thevisualization, or manipulate the measurement of the formation signal. Insome instances, the manipulation of the visualization can include hidinga colored iso-parameter or adding another colored iso-parameter. Theinput can also allow the user to manipulate the three dimensionalvisualization by smoothing an iso-parameter surface.

At block 914, at least one parameter of the well-logging operation isdetermined. The input can allow a user to specify the parameters for amore detailed logging pass, such as beginning/end, depth, speed, or anyother logging parameter to provide a more detailed view of a criticalcasing segment.

FIG. 10 illustrates an example method 1000 for using an interactivevirtual reality apparatus 100 within an cased hole service operation.The method 1000 can be a specific iteration of method 800 describedabove with respect to FIG. 8 . Referring to FIG. 10 , a flowchart ispresented in accordance with an example embodiment. The example method1000 is provided by way of example, as there are a variety of ways tocarry out the method 1000. The method 1000 described below can becarried out using the configurations illustrated in FIGS. 1-8 , forexample, and various elements of these figures are referenced inexplaining example method 1000. Each block shown in FIG. 10 representsone or more processes, methods or subroutines, carried out in theexample method 1000. Furthermore, the illustrated order of blocks isillustrative only and the order of the blocks can change according tothe present disclosure. Additional blocks may be added or fewer blocksmay be utilized, without departing from this disclosure. The examplemethod 1000 can begin at block 1002.

At block 1002, the downhole measurement comprises a cased-hole pipeservice operation. The cased-hole pipe is measured by a downhole tool.

At block 1004, the cased-hole pipe casing property is interpreted. Theinterpretation of the casing property can occur across multiple pipeswithin the cased-hole. In some instances, the casing property is adefect. In some instances the downhole measurement of block 1002 andinterpretation of block 1004 can be combined to produce a measuredsignal.

At block 1006, one or more surfaces can be constructed from theinterpreted casing properties across multiple pipes. The one or moreconstructed surfaces can represent multiple concentric casing pipes.

At block 1008, the one or more surfaces can be visualized either frominside or outside of the casing pipe. The visualization can be a threedimensional visualization displayed in the stereographic viewer andallow the user to see the measured signal in a three dimensionalenvironment. The three dimensional visualization can represent a casingproperty including, but not limited to, metal loss, defects, and surfaceprofile.

At block 1010, the three dimensional visualization can be manipulatedusing the gesture control device. The three dimensional visualizationcan be manipulated to remove and/or smooth over known defects on thecasing, such as casing collars and perforations, thereby allowing otherdefects (e.g. corrosion) to stand out.

At block 1012, the three dimensional visualization can also bemanipulated to set determine one or more parameters for a succeedingpipe service run. In some instances, the succeeding pip service run canbe a more detailed logging pass, such as beginning/end depth, speed,etc.

FIG. 11 illustrates an example method 1100 for using an interactivevirtual reality apparatus 100 for controlling a well monitoring system.The method 1100 can be a specific iteration of method 800 describedabove with respect to FIG. 8 . Referring to FIG. 11 , a flowchart ispresented in accordance with an example embodiment. The example method1100 is provided by way of example, as there are a variety of ways tocarry out the method 1100. The method 1100 described below can becarried out using the configurations illustrated in FIGS. 1-8 , forexample, and various elements of these figures are referenced inexplaining example method 1100. Each block shown in FIG. 11 representsone or more processes, methods or subroutines, carried out in theexample method 1100. Furthermore, the illustrated order of blocks isillustrative only and the order of the blocks can change according tothe present disclosure. Additional blocks may be added or fewer blocksmay be utilized, without departing from this disclosure. The examplemethod 1100 can begin at block 1102.

At block 1102, one or more sensors can be deployed within a completedwellbore. The one or more sensors can be disposed along the length ofcased wellbore and configured to monitor one or more borehole parameters(e.g. temperature, pressure, chemical composition, etc.) at variousdepths. In some instances, the one or more sensors are permanent sensorsdisposed within an intelligent well completion. Fiber optic lines canalso be conveyed downhole for temperature, pressure, or strain sensingand can be permanent or temporary. The one or more sensors can yielddistributed data over the entire length of the fiber or at one or morealong the fiber.

At block 1104, the one or more sensors measure predetermined parametersat various depths.

At block 1106, the one or more sensors measure temperature, pressure,strain, and/or chemical composition.

At block 1108, colored isometric surfaces, or colored volumetric fogsare formed using the data collected from the one or more sensors.

At block 1110, a three dimensional visualization is formed. The coloredisometric surfaces can be overlaid with the borehole surfaces or themonitoring data can be represented as three dimensional volumetric fog.In some instances, a temperature map, pressure map, or strain map can beoverlaid with the borehole surfaces.

At block 1112, the user can manipulate data in the three dimensionalvisualization using the gesture control device.

At block 1114, the user can modify at least one parameter of production,such as hydraulic fracturing parameters, production zone isolation, flowcontrol, valve opening/shut-off, etc. These controls can be present inthe three dimensional interactive virtual reality apparatus via buttons,menus, and/or other GUI features. In some instances, the user can modifythe three dimensional visualization itself, such as smoothing over athree dimensional surface representation or otherwise manipulated by thegesture control device.

FIG. 12 illustrates an example method 1200 for using an interactivevirtual reality apparatus 100 for permanent reservoir monitoringoperation, in some instances in an enhanced oil recovery (EOR) scenario.The method 1200 can be a specific iteration of method 800 describedabove with respect to FIG. 8 . Referring to FIG. 12 , a flowchart ispresented in accordance with an example embodiment. The example method1200 is provided by way of example, as there are a variety of ways tocarry out the method 1200. The method 1200 described below can becarried out using the configurations illustrated in FIGS. 1-8 , forexample, and various elements of these figures are referenced inexplaining example method 1200. Each block shown in FIG. 12 representsone or more processes, methods or subroutines, carried out in theexample method 1200. Furthermore, the illustrated order of blocks isillustrative only and the order of the blocks can change according tothe present disclosure. Additional blocks may be added or fewer blocksmay be utilized, without departing from this disclosure. The examplemethod 1200 can begin at block 1202.

At block 1202, one or more permanent reservoir monitoring sensors aredeployed in a completed well. The one or more sensors can be distributedalong the length of the well. In some instances, the one or more sensorsare evenly distributed along the length or can be distributed withhigher density at predetermined depths having particular interest.

At block 1204, the one or more permanent reservoir monitoring sensorsmake sensor measurements at various depths.

At block 1206, the one or more permanent reservoir monitoring sensorsmeasure at least one of distance to water/CO₂ front or formationresistivity map. In EOR, an injection well injects an injecting agent(water or CO₂) into the formation to enhance projection in a nearbyproduction well by displacing the hydrocarbons in the surroundingformation. The one or more sensors can detect and measure the shapeand/or distance of the incoming water or CO₂ front.

At block 1208, the method 1200 can construct a surface for the water/CO2front or a colored volumetric fog for the formation resistivity map.

At block 1210, a three dimensional visualization is formed. The coloredisometric surfaces can be overlaid with the borehole surfaces or themonitoring data can be represented as three dimensional volumetric fog.The incoming water or CO2 front can be represented in three dimensionsas a virtual surface or a series of virtual surfaces. Alternatively, aformation property, such as resistivity, slowness, or the like,indicating the presence of the injection agent can be represented as athree dimensional volumetric fog.

At block 1212, the user can manipulate data in the three dimensionalvisualization using the gesture control device.

At block 1214, the user can modify at least one parameter of productionor injection. In response to the three dimensional visualization, theuser can virtually control the injection well and/or the production welldepending on the state of the incoming water or CO₂ front. In someinstances, the injection zones on the injection well can be manipulatedvirtually or the valves on the production well can be virtuallyopened/shut off at certain areas.

FIG. 13 illustrates an example method 1300 for using an interactivevirtual reality apparatus 100 for distance to a bed boundary (DTBB)measurement. The method 1300 can be a specific iteration of method 800described above with respect to FIG. 8 . Referring to FIG. 13 , aflowchart is presented in accordance with an example embodiment. Theexample method 1300 is provided by way of example, as there are avariety of ways to carry out the method 1300. The method 1300 describedbelow can be carried out using the configurations illustrated in FIGS.1-8 , for example, and various elements of these figures are referencedin explaining example method 1300. Each block shown in FIG. 13represents one or more processes, methods or subroutines, carried out inthe example method 1300. Furthermore, the illustrated order of blocks isillustrative only and the order of the blocks can change according tothe present disclosure. Additional blocks may be added or fewer blocksmay be utilized, without departing from this disclosure. The examplemethod 1300 can begin at block 1302.

At block 1302, the downhole measurements can include a MWD operationthat measures a DTBB and the resistivities on the two sides of theboundary.

At block 1304, the method 1300 can create surfaces from multipledistance measurements. The boundary can be represented as a surface inthe three dimensional view.

At block 1306, the method 1300 can project the resistivity as color ofthe surface or color of a volumetric fog.

At block 1308, the surfaces can be visualized in three dimensions alongwith the wellbore trajectory. The past wellbore trajectory and thefuture (projected or estimated) wellbore trajectory can also be overlaidon the three dimensional visualization of the downhole measurements. Themethod 1300 can proceed to block 1310 for manipulation of the surfacesor block 1312 for visualization a bottom hole assembly (BHA).

At block 1310, the surfaces and/or wellbore trajectory can bemanipulated using the gesture control device.

At block 1312, the method 1300 generates a visualization of a virtualrepresentation of a BHA orientation or future wellbore path. The usercan virtually manipulate the future wellbore trajectory using handgestures, virtual buttons and/or virtual menus.

At block 1314, the BHA orientation or future wellbore path can be bemanipulated by the user as a result of interaction with the gesturecontrol device. The user can virtually manipulate the future wellborepath using hand gestures, virtual buttons and/or virtual menus. Thevirtual manipulation can then be processed and transmitted to thedrilling system as the method proceeds to block 1316.

At block 1316, the drilling system and the BHA can geosteer to thedirection indicated by the manipulated orientation or path.

FIG. 14 illustrates an example method 1400 for using an interactivevirtual reality apparatus 100 for shallow drilling operation, in someinstances steam assisted gravity drainage (SAGD). The method 1400 can bea specific iteration of method 800 described above with respect to FIG.8 . Referring to FIG. 14 , a flowchart is presented in accordance withan example embodiment. The example method 1400 is provided by way ofexample, as there are a variety of ways to carry out the method 1400.The method 1400 described below can be carried out using theconfigurations illustrated in FIGS. 1-8 , for example, and variouselements of these figures are referenced in explaining example method1400. Each block shown in FIG. 14 represents one or more processes,methods or subroutines, carried out in the example method 1400.Furthermore, the illustrated order of blocks is illustrative only andthe order of the blocks can change according to the present disclosure.Additional blocks may be added or fewer blocks may be utilized, withoutdeparting from this disclosure. The example method 1400 can begin atblock 1402.

At block 1402, a downhole measurement can be received and a threedimensional visualization formed thereof. The downhole measurement cancollect information on near surface geology and man-made structures, forexample, pipes, building foundations, etc. and overlaid on with a viewof a drilling site.

At block 1404, the stereographic display device can measure a user'shead orientation and/or roll. The stereographic display device caninclude the gesture control device through the implementation of one ormore accelerometers, gyroscopes, or other related sensors.

At block 1406, the stereographic display device can measure a user'shead position. The user's starting head position and orientation can setas an initial position to determine movement and position relativethereto for use as a gesture control device.

At block 1408, project near surface geology, actual or desired man-madestructures on the stereographic display device generating a virtual oraugmented reality. Movement of the user's head adjusts in real-time theoverlaid image of the downhole measurements along with the drilling siteproviding an augmented reality.

At block 1410, a drilling or construction operation can be performedbased on the projected image.

At block 1412, geosteering can be performed based on the projectedimage.

FIG. 15A illustrates an example method 1500 for using an interactivevirtual reality apparatus 100 for caliper measurements. The method 1500can be a specific iteration of method 800 described above with respectto FIG. 8 . Referring to FIG. 15A, a flowchart is presented inaccordance with an example embodiment. The example method 1500 isprovided by way of example, as there are a variety of ways to carry outthe method 1500. The method 1500 described below can be carried outusing the configurations illustrated in FIGS. 1-8 , for example, andvarious elements of these figures are referenced in explaining examplemethod 1500. Each block shown in FIG. 15A represents one or moreprocesses, methods or subroutines, carried out in the example method1500. Furthermore, the illustrated order of blocks is illustrative onlyand the order of the blocks can change according to the presentdisclosure. Additional blocks may be added or fewer blocks may beutilized, without departing from this disclosure. The example method1500 can begin at block 1502.

At block 1502, a caliper measurement is made to construct a threedimensional virtual surface representation a borehole wall. Duringdrilling operations, a drill bit is regularly removed replaced during a‘bit trip’ in which the drill string is removed from the wellbore. Awireline tool string can be lowered into the borehole for measurementsincluding a caliper measurement.

At block, 1504, a borehole resistivity imager can provide a shallowresistivity map of the borehole wall.

At block 1506, a borehole surface is constructed from the calipermeasurement.

At block 1508, the resistivity map is projected on to the constructedsurface.

At block 1510, the projection is visualized by a user via astereographic display device.

At block 1512, the user can control the visualization via the gesturecontrol device including head movements. The user can zoom in onportions of the three dimensional visualization to determine conditionswithin the wellbore and whether the appropriate drilling mud is beingutilized. Problems such as over-invasion and/or washout can be diagnosedand mud properties adjusted appropriately.

At block 1514, the mud properties can be adjusted to correct thediagnosed problems within the wellbore.

FIG. 15B illustrates an example method 1550 for using an interactivevirtual reality apparatus 100 for caliper measurements. The method 1550can be a specific iteration of method 800 described above with respectto FIG. 8 . Referring to FIG. 15B, a flowchart is presented inaccordance with an example embodiment. The example method 1550 isprovided by way of example, as there are a variety of ways to carry outthe method 1550. The method 1550 described below can be carried outusing the configurations illustrated in FIGS. 1-8 , for example, andvarious elements of these figures are referenced in explaining examplemethod 1550. Each block shown in FIG. 15B represents one or moreprocesses, methods or subroutines, carried out in the example method1550. Furthermore, the illustrated order of blocks is illustrative onlyand the order of the blocks can change according to the presentdisclosure. Additional blocks may be added or fewer blocks may beutilized, without departing from this disclosure. The example method1550 can begin at block 1552.

At block 1502, a borehole imager can provide a shallow resistivity mapof the borehole wall. During drilling operations, a drill bit isregularly removed replaced during a ‘bit trip’ in which the drill stringis removed from the wellbore. A wireline tool string can be lowered intothe borehole for measurements including a borehole imager.

At block, 1554, the borehole resistivity imager can provide a deepresistivity map of the borehole wall.

At block 1556, an equal resistivity borehole surface is constructed fromthe shallow and deep measurements.

At block 1558, the deep resistivity image is projected on to theconstructed surface.

At block 1560, the projection is visualized by a user via astereographic display device.

At block 1562, the user can control the visualization via the gesturecontrol device including head movements. The shape and resistivity ofthe constructed surface can yield information on the condition of theborehole. The user can zoom in on portions of the three dimensionalvisualization to determine conditions within the wellbore and whetherthe appropriate drilling mud is being utilized. Problems such asover-invasion and/or washout can be diagnosed and mud propertiesadjusted appropriately.

At block 1564, the mud properties can be adjusted to correct thediagnosed problems within the wellbore.

FIG. 16 illustrates an example method 1600 for using an interactivevirtual reality apparatus 100 to generate a false three dimensionalview. The method 1600 can generate a false three dimensionalvisualization using the stereographic display device to overlay twoimages of the same feature, thereby “tricking” a user's brain to detectany difference between the two images as depth. If the two images areidentical, the depth dimension appears to be at infinity (or very faraway). The more differences within the two images, the closer the threedimensional visualization is perceived. The two images can be comparedby projecting one of the left eye and the other on the right eye of thestereographic display device and interpreting the depth perceptionresulting from their difference. In some instances, the two images canbe generated by different measurement devices within a wellbore. Inother instances, the two images can be generated by the same measurementdevice at different times, sensitivities, and/or sampling rates, etc.

Referring to FIG. 16 , a flowchart is presented in accordance with anexample embodiment. The example method 1600 is provided by way ofexample, as there are a variety of ways to carry out the method 1600.The method 1600 described below can be carried out using theconfigurations illustrated in FIGS. 1-7 , for example, and variouselements of these figures are referenced in explaining example method1600. Each block shown in FIG. 16 represents one or more processes,methods or subroutines, carried out in the example method 1600.Furthermore, the illustrated order of blocks is illustrative only andthe order of the blocks can change according to the present disclosure.Additional blocks may be added or fewer blocks may be utilized, withoutdeparting from this disclosure. The example method 1600 can begin atblock 1602.

At block 1602, a casing, borehole, or formation property is presented.

At block 1604, a downhole measurement device is disposed within thewellbore to measure the casing, borehole, or formation property. In someinstances, more than one downhole measurement device can be disposedwithin the wellbore to measure the casing, borehole, and/or formationproperty.

At block 1606, a first measured signal can be generated by the downholemeasurement device and associated as the left signal.

At block 1608, a second measured signal can be generated by the downholemeasurement device and associated as the right signal. In someinstances, the second measured signal can be generated using thedownhole measurement device used to generate the first measured signal.In other instances, a different downhole measurement device can be usedto generate the second measured signal.

At block 1610, the first measured signal and the second measured signalcan be processed. Processing can require normalizing and otherwiseprocessing the measured signal.

At block 1612, the first measured signal is normalized and processed togenerate a first image, or left image.

At block 1614, the second measured signal is normalized and processed togenerate a second image, or right image.

At block 1616, the first image and second image can be displayed by thestereographic display device as a stereo projection.

At block 1618, the stereo projection can form a visualization. Thevisualization, when viewed by a user, can generate a three dimensionalimage as the user's brain detects differences between the first imageand the second image as depth, thereby forming a three dimensionalviritualization. In some instances, the user can manipulate the threedimensional visualization using a gesture control device.

FIG. 17A illustrates an example method 1700 for using an interactivevirtual reality apparatus 100 for downhole measurements. The method 1700can be a specific iteration of method 1600 described above with respectto FIG. 16 . Referring to FIG. 17A, a flowchart is presented inaccordance with an example embodiment. The example method 1700 isprovided by way of example, as there are a variety of ways to carry outthe method 1700. The method 1700 described below can be carried outusing the configurations illustrated in FIGS. 1-7 , for example, andvarious elements of these figures are referenced in explaining examplemethod 1700. Each block shown in FIG. 17A represents one or moreprocesses, methods or subroutines, carried out in the example method1700. Furthermore, the illustrated order of blocks is illustrative onlyand the order of the blocks can change according to the presentdisclosure. Additional blocks may be added or fewer blocks may beutilized, without departing from this disclosure. The example method1700 can begin at block 1702.

At block 1702, a downhole measurement device generates a casing,borehole, and/or formation property measurement.

At block 1704, a downhole measurement device generates a repeatedcasing, borehole, and/or formation property measurement. In someinstances, the downhole measurement device repeats the measurementwithout any change to the logging parameters. In other instances, adifferent downhole measurement device is used and/or different loggingparameters are implemented.

At block 1706, the stereographic display device projects the firstmeasurement to the left eye.

At block 1708, the stereographic display device projects the repeatedmeasurement to the right eye.

At block 1710, a visualization is formed by a user viewing the firstmeasurement in the left eye and the repeated measurement in the righteye, thereby forming a three dimensional visualization.

At block 1712, the stereographic display device presenting the firstmeasurement to the left eye and the repeated measurement to the righteye causes the user's brain to view difference between the firstmeasurement and the repeated measurement as depth, thereby forming athree dimensional viritualization. In some instances, the user canmanipulate the three dimensional visualization using a gesture controldevice.

FIG. 17B illustrates an example first measurement 1752 and an examplerepeated measurement 1754. The measurements 1750 can be presented to auser via the stereographic display device allowing the user to determinedifference between the first measurement 1752 and the repeatedmeasurement 1754. The first measurement 1752 can be taken with adownhole tool, and the repeated measurement 1754 can be taken with thedownhole tool at a different time or with different measurementparameters.

FIG. 18A illustrates an example method 1800 for using an interactivevirtual reality apparatus 100 for downhole measurements. The method 1800can be a specific iteration of method 1600 described above with respectto FIG. 16 . Referring to FIG. 18A, a flowchart is presented inaccordance with an example embodiment. The example method 1800 isprovided by way of example, as there are a variety of ways to carry outthe method 1800. The method 1800 described below can be carried outusing the configurations illustrated in FIGS. 1-7 , for example, andvarious elements of these figures are referenced in explaining examplemethod 1800. Each block shown in FIG. 18A represents one or moreprocesses, methods or subroutines, carried out in the example method1800. Furthermore, the illustrated order of blocks is illustrative onlyand the order of the blocks can change according to the presentdisclosure. Additional blocks may be added or fewer blocks may beutilized, without departing from this disclosure. The example method1800 can begin at block 1802.

At block 1802, a downhole measurement device generates a casing,borehole, and/or formation property measurement.

At block 1804, a second downhole measurement device generates a secondcasing, borehole, and/or formation property measurement. The seconddownhole measurement device can take a measurement using differentphysics from the downhole measurement device and/or different loggingparameters.

At block 1806, the stereographic display device projects the firstmeasurement to the left eye.

At block 1808, the stereographic display device projects the secondmeasurement to the right eye.

At block 1810, a visualization is formed by a user viewing the firstmeasurement in the left eye and the second measurement in the right eye,thereby forming a three dimensional visualization.

At block 1812, the stereographic display device presenting the firstmeasurement to the left eye and the second measurement to the right eyecauses the user's brain to view difference between the first measurementand the second measurement as depth, thereby forming a three dimensionalviritualization. In some instances, the user can manipulate the threedimensional visualization using a gesture control device.

FIG. 18B illustrates an example first measurement 1852 and an examplesecond measurement 1854. The measurements 1850 can be presented to auser via the stereographic display device allowing the user to determinedifference between the first measurement 1852 and the second measurement1854. The first measurement 1852 can be taken with a downhole tool, andthe repeated measurement 1854 can be taken with a second downhole tooloperating under a different measurement technique. In some instances,the downhole tool can provide a shallow resisitivity map of the boreholewall while the second downhole tool can provide an acoustic slowness mapof the borehole wall. These two downhole measurements can besubstantially normalized and/or color matched to allow a user toperceive differences between them as depth.

The present disclosure is suited for use in any drilling operation thatgenerates a subterranean borehole. For example, the present disclosureis suited to drilling for hydrocarbon or mineral exploration,environmental investigations, natural gas extraction, undergroundinstallation, mining operations, water wells, geothermal wells, and thelike.

Statement of Claims

Statement 1: A method for visualization and manipulation of downholedata, comprising: receiving a measured signal of a downhole environment;generating a three dimensional virtualization of the measured signal;displaying, on a stereographic viewer, the three dimensionalvirtualization of the measured signal; manipulating the threedimensional virtualization in response to an input from a user, therebycreating a manipulated three dimensional virtualization; and displaying,on the stereographic viewer, the manipulated three dimensionalvirtualization.Statement 2: The method of Statement 1, further comprising adjusting awell bore operation based on the manipulated three dimensionvirtualization.Statement 3: The method according to one of Statement 1 or Statement 2,wherein the measured signal is one of a well-logging, casing inspection,permanent reservoir monitoring, or a measurement while drilling (MWD)operation.Statement 4: The method according to any one of the preceding Statements1-3, wherein the stereo graphic viewer includes a head tracking systemand the head tracking system generates the input.Statement 5: The method according to any one of the preceding Statements1-4, wherein the head tracking system has at least one of a gyroscope,an accelerometer, or image processing.Statement 6: The method according to any one of the preceding Statements1-5, wherein input is received from a gesture control device or a headtracking system.Statement 7: The method according to any one of the preceding Statements1-6, wherein the input is received by one or more virtual buttonsconfigured to manipulate the three dimensional virtualization.Statement 8: The method according to any one of the preceding Statements1-7, wherein the one or more virtual buttons include at least one ofscroll bars, dropdown menus, or checkboxes.Statement 9: The method according to any one of the preceding Statements1-8, further comprising determining at least one parameter of awell-logging, casing inspection, or drilling operation in response tothe input from a user.Statement 10: The method according to Statement 9, wherein determiningthe at least one parameter of a well-logging or casing inspectionoperation is specifying the settings of the next logging run or pass.Statement 11: The method according to one of Statement 9 or Statement10, wherein determining the at least one parameter of a drillingoperation is geosteering.Statement 12: The method according to any one of Statements 9-11,wherein determining the at least one parameter of a drilling operationis appropriate drilling mud propertiesStatement 13: The method any one of the preceding Statements 1-12,further comprising modifying at least one production parameter inresponse to the input from a user.Statement 14: The method of Statement 13, wherein modifying the at leastone production parameter is one of opening a valve on a production well,closing a valve on a production well, or changing hydraulic fracturingparameters.Statement 15: A system for visualization and manipulation of downholedata, comprising: an interactive virtual reality apparatus having astereographic display device and a gesture control device; an electronicdevice communicatively coupled with the interactive virtual realityapparatus, the electronic device having a processor and a memory, thememory storing instructions, which when executed cause the processor to:receive a measured signal of a downhole environment; generate a threedimensional virtualization of the measured signal; communicate the threedimensional virtualization to the interactive virtual reality apparatus;manipulate the three dimensional virtualization in response to an inputfrom the interactive virtual reality apparatus, thereby creating amanipulated three dimensional virtualization; and communicate themanipulated three dimensional virtualization to the interactive virtualreality apparatus.Statement 16: The system of Statement 15, further comprising the memorystoring instructions, which when executed cause the processor to adjusta well bore operation based on the manipulated three dimensionvirtualization.Statement 17: The system according Statement 15 or Statement 16, whereinthe gesture control device is a head tracking system communicativelycoupled with the stereographic display device.Statement 18: The system according any one of the preceding Statements15-17, wherein the gesture control device is configured to be coupledwith at least one extremity of a user, the gesture control device havingone or more sensors tracking movement of the at least one extremity.Statement 19: A computer-readable storage device having instructionsstored which, when executed by a computing device, cause the computingdevice to perform operations comprising: receiving a measured signal ofa downhole environment; generating a three dimensional virtualization ofthe measured signal; communicating the three dimensional virtualizationto an interactive virtual reality apparatus; manipulating the threedimensional virtualization in response to an input from the interactivevirtual reality apparatus, to yield a manipulated three dimensionalvirtualization, thereby creating a manipulated three dimensionalvirtualization; and communicating the manipulated three dimensionalvirtualization to the interactive virtual reality apparatus.Statement 20: The system of Statement 19, further comprising the memorystoring instructions, which when executed cause the processor toadjusting a well bore operation based on the manipulated three dimensionvirtualization.Statement 21: The system of Statement 19 or Statement 20, wherein thegesture control device is a head tracking system communicatively coupledwith the stereographic display device.Statement 22: The system according any one of the preceding Statements18-21, wherein the gesture control device is configured to be coupledwith at least one extremity of a user, the gesture control device havingone or more sensors tacking movement of the at least one extremity.Statement 23: A method for visualization of downhole data, comprising:

receiving a left measured signal of a downhole environment and a rightmeasured signal of the downhole environment, processing the leftmeasured signal to generate a left image and the right measured signalto generate a right image, displaying, on a stereographic viewer, theleft image to a user's left eye and the right image to a user's righteye, thereby forming a three dimensional virtualization, and whereinvariation between the left measured signal and the second measuredsignal is perceived as three dimensional depth changes in the threedimensional virtualization.

Statement 24: The method according to Statement 23, wherein the leftmeasured signal has a first set of logging parameters and the rightmeasured signal has a second set of logging parameters.

Statement 25: The method according to Statement 23 or Statement 24,wherein the left measured signal is based on a first physics and thesecond measured signal is based on a second physics.

Statement 26: A method for visualization and manipulation of downholedata, comprising receiving a measured signal of a downhole environment,displaying, on a stereographic viewer, a three dimensionalvirtualization based on the measured signal, manipulating the threedimensional virtualization in response to an input from a user, therebycreating a manipulated three dimensional virtualization, and displaying,on the stereographic viewer, the manipulated three dimensionalvirtualization.Statement 27: The method according to Statement 26, further comprisinggenerating a three dimensional model based on the measured signal, anddisplaying, on the stereographic viewer, the three dimensionalvirtualization based on the three dimensional model.Statement 28: The method according to Statement 26 or Statement 27,wherein displaying the three dimensional virtualization based on themeasured signal comprises displaying, on the stereographic viewer, aleft image to a user's left eye and a right image to a user's right eye,wherein at least one or both of the left image and the right image isbased on the measured signal.Statement 29: The method of according to Statement 28, generating threedimensional depth changes in the three dimensional virtualization due toa variation between the left image and the right image.Statement 30: The method according to Statement 28, further comprisingreceiving a left measured signal of a downhole environment and a rightmeasured signal of the downhole environment, and displaying, on thestereographic viewer, the left image based on the left measured signal,and the right image based on the right measured signal.Statement 31: The method according to Statement 30, wherein the leftmeasured signal is based on a first physics and the second measuredsignal is based on a second physics.Statement 32: The method according to any one of Statements 28-31,wherein the measured signal of a downhole environment is at least one ormore of a formation property, a casing property, casing defect,temperature, pressure, chemical composition, distance to water/CO₂,distance to a bed boundary (DTBB), caliper measurement, resistivity,steam assisted gravity drainage, near surface geology, and man-madestructures.Statement 33: The method according to any one of Statements 28-32,wherein the displayed three dimensional virtualization is a colorediso-parameter surfaces and/or colored volumetric fog of a borehole orcasing.Statement 34: The method according to any one of Statements 28-33,wherein input is received from a gesture control device or a headtracking system.Statement 35: The method according to Statement 34, wherein manipulatingthe three dimensional virtualization comprises smoothing virtualizedsurfaces.Statement 36: The method according to Statement 34, further comprisingdetermining at least one parameter of a well-logging, casing inspection,or drilling operation in response to the input from a user.Statement 37: The method according to Statement 34, wherein determiningthe at least one parameter of a well-logging or casing inspectionoperation is one of specifying the settings of the next logging run orgeosteering.

What is claimed is:
 1. A method for visualization and manipulation ofdownhole data in a well monitoring system, comprising: receiving ameasured signal of a downhole environment representing a plurality offormation properties; displaying, on a stereographic viewer, a threedimensional virtualization based on the measured signal, wherein eachformation property is represented by a different colored iso-parametersurface; manipulating the three dimensional virtualization in responseto an input from a user, thereby creating a manipulated threedimensional virtualization; displaying, on the stereographic viewer, themanipulated three dimensional virtualization, wherein the manipulatedthree dimensional visualization includes at least one control formodifying at least one parameter of production for the well monitoringsystem; and modifying the at least one parameter of production inresponse to interaction by the user with the at least one control,wherein the three dimensional virtualization is manipulated by hiding acolored iso-parameter surface representing one formation property of theplurality of formation properties.
 2. The method of claim 1, furthercomprising: generating a three dimensional model based on the measuredsignal; and displaying, on the stereographic viewer, the threedimensional virtualization based on the three dimensional model.
 3. Themethod of claim 1, wherein displaying the three dimensionalvirtualization based on the measured signal comprises: displaying, onthe stereographic viewer, a left image to a user's left eye and a rightimage to a user's right eye, wherein at least one or both of the leftimage and the right image is based on the measured signal.
 4. The methodof claim 3, generating three dimensional depth changes in the threedimensional virtualization due to a variation between the left image andthe right image.
 5. The method of claim 3, further comprising receivinga left measured signal of the downhole environment and a right measuredsignal of the downhole environment, and displaying, on the stereographicviewer, the left image based on the left measured signal, and the rightimage based on the right measured signal.
 6. The method of claim 5,wherein the left measured signal is based on a first physics and theright measured signal is based on a second physics.
 7. The method ofclaim 1, wherein the measured signal of the downhole environment is atleast one or more of a formation property, a casing property, casingdefect, temperature, pressure, chemical composition, distance towater/CO₂, distance to a bed boundary (DTBB), caliper measurement,resistivity, steam assisted gravity drainage, near surface geology, andman-made structures.
 8. The method of claim 1, wherein interaction bythe user with the at least one control is performed by a gesture controldevice or a head tracking system.
 9. The method of claim 1, furthercomprising determining at least one parameter of a well-logging, casinginspection, or drilling operation in response to the input from theuser.
 10. The method of claim 9, wherein determining the at least oneparameter of a well-logging or casing inspection operation is one ofspecifying a plurality of settings of a next logging run or geosteering.11. The method of claim 1, wherein the at least one parameter ofproduction comprises valve opening or shut-off.
 12. The method of claim1, wherein the at least one parameter of production comprises at leastone hydraulic fracturing parameter.
 13. The method of claim 1, whereinthe at least one parameter of production comprises at least oneproduction zone production parameter.